{"title":"Calculating the Total Porosity of Shale Reservoirs by Combining Conventional Logging and Elemental Logging to Eliminate the Effects of Gas Saturation","authors":"Linqi Zhu, Chong Zhang, Cong Guo, Yifeng Jiao, Lie Chen, Xueging Zhou, Chaomo Zhang, Zhansong Zhang","doi":"10.30632/PJV59N2-2018A4","DOIUrl":"https://doi.org/10.30632/PJV59N2-2018A4","url":null,"abstract":"","PeriodicalId":49703,"journal":{"name":"Petrophysics","volume":"59 1","pages":"162-184"},"PeriodicalIF":0.9,"publicationDate":"2018-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"43675591","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Haijing Wang, Hanming Wang, Emmauel Toumelin, Ronald L. Brown, Luisa Crousse
{"title":"Improving Dielectric Interpretation by Calibrating Matrix Permittivity and Solving Dielectric Mixing Laws With a New Graphical Method","authors":"Haijing Wang, Hanming Wang, Emmauel Toumelin, Ronald L. Brown, Luisa Crousse","doi":"10.30632/PJV59N2-2018A5","DOIUrl":"https://doi.org/10.30632/PJV59N2-2018A5","url":null,"abstract":"","PeriodicalId":49703,"journal":{"name":"Petrophysics","volume":"59 1","pages":"185-200"},"PeriodicalIF":0.9,"publicationDate":"2018-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"47963314","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
H. King, M. Sansone, P. Kortunov, Ye Xe, Nicole M Callen, Sheerang Chhartre, H. Sahoo, A. Buono
1. ABSTRACT Recent studies on several core-plug scale samples from tight oil reservoirs have demonstrated that such rocks can exhibit a significant, irreversible permeability decline with increase in net confining stress. Because this effect closely follows the expected stress change during drawdown in the field, the origins of this phenomena as well as a method to predict the magnitude relative to different rock types is valuable information for reservoir management. To better understand this effect, we have undertaken a series of in situ studies that demonstrate how an external stress field translates to microscopic strain at the pore scale and couples to the fluid transport. These studies rely on the coordinated use of low-field Nuclear Magnetic Resonance (NMR) and X-ray Microtomography (XMT). Making use of labeled fluids to enhance contrast, we are able to directly resolve how local strains affect fluid transport throughout the core plug. In a similar manner, proton NMR resolves how stress couples to deformation of the various pore systems, affecting the fluid content and their dynamics. Together, these techniques indicate that internal, high-permeability pathways play an important role in the stress dependence. Matrix permeability is much less affected. These higher-permeability zones are not ubiquitous in tight-oil rocks. Characterizing these zones and relating them to mineralogy and rock fabric is an attractive pathway to greater predictability for stressdependent permeability for reservoir rock types.
{"title":"Microstructural Investigation of Stress-Dependent Permeability in Tight-Oil Rocks","authors":"H. King, M. Sansone, P. Kortunov, Ye Xe, Nicole M Callen, Sheerang Chhartre, H. Sahoo, A. Buono","doi":"10.30632/PETRO_059_1_A3","DOIUrl":"https://doi.org/10.30632/PETRO_059_1_A3","url":null,"abstract":"1. ABSTRACT Recent studies on several core-plug scale samples from tight oil reservoirs have demonstrated that such rocks can exhibit a significant, irreversible permeability decline with increase in net confining stress. Because this effect closely follows the expected stress change during drawdown in the field, the origins of this phenomena as well as a method to predict the magnitude relative to different rock types is valuable information for reservoir management. To better understand this effect, we have undertaken a series of in situ studies that demonstrate how an external stress field translates to microscopic strain at the pore scale and couples to the fluid transport. These studies rely on the coordinated use of low-field Nuclear Magnetic Resonance (NMR) and X-ray Microtomography (XMT). Making use of labeled fluids to enhance contrast, we are able to directly resolve how local strains affect fluid transport throughout the core plug. In a similar manner, proton NMR resolves how stress couples to deformation of the various pore systems, affecting the fluid content and their dynamics. Together, these techniques indicate that internal, high-permeability pathways play an important role in the stress dependence. Matrix permeability is much less affected. These higher-permeability zones are not ubiquitous in tight-oil rocks. Characterizing these zones and relating them to mineralogy and rock fabric is an attractive pathway to greater predictability for stressdependent permeability for reservoir rock types.","PeriodicalId":49703,"journal":{"name":"Petrophysics","volume":"59 1","pages":"35-43"},"PeriodicalIF":0.9,"publicationDate":"2018-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"43029024","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
{"title":"Study on the Mechanism of Geostress Difference Effect on Tight Sandstone Resistivity and Its Correction Method","authors":"Zhiying Liu, Chengguang Zhang, G. Zheng, Yi Xin","doi":"10.30632/PETRO_059_1_A8","DOIUrl":"https://doi.org/10.30632/PETRO_059_1_A8","url":null,"abstract":"","PeriodicalId":49703,"journal":{"name":"Petrophysics","volume":"59 1","pages":"82-98"},"PeriodicalIF":0.9,"publicationDate":"2018-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"48041160","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
{"title":"Using Digital Rock Technology to Quality Control and Reduce Uncertainty in Relative Permeability Measurements","authors":"J. Schembre-Mccabe, J. Kamath","doi":"10.30632/PETRO_059_1_A4","DOIUrl":"https://doi.org/10.30632/PETRO_059_1_A4","url":null,"abstract":"","PeriodicalId":49703,"journal":{"name":"Petrophysics","volume":"59 1","pages":"44-53"},"PeriodicalIF":0.9,"publicationDate":"2018-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"42251078","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
{"title":"New Perspectives on the Effects of Gas Adsorption on Storage and Production of Natural Gas From Shale Formations","authors":"A. Tinni, C. Sondergeld, C. Rai","doi":"10.30632/PETRO_059_1_A9","DOIUrl":"https://doi.org/10.30632/PETRO_059_1_A9","url":null,"abstract":"","PeriodicalId":49703,"journal":{"name":"Petrophysics","volume":"59 1","pages":"99-104"},"PeriodicalIF":0.9,"publicationDate":"2018-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"45798460","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
{"title":"What is it about Shaly Sands? Shaly Sand Tutorial No. 2 of 3","authors":"E. C. Thomas","doi":"10.30632/PJV59N2-2018T1","DOIUrl":"https://doi.org/10.30632/PJV59N2-2018T1","url":null,"abstract":"","PeriodicalId":49703,"journal":{"name":"Petrophysics","volume":"59 1","pages":"276-287"},"PeriodicalIF":0.9,"publicationDate":"2018-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"45163429","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
{"title":"Using a Densitometer for Quantitative Determinations of Fluid Density and Fluid Volume in Coreflooding Experiments at Reservoir Conditions","authors":"D. Olsen, Greenland","doi":"10.30632/PETRO_059_1_A5","DOIUrl":"https://doi.org/10.30632/PETRO_059_1_A5","url":null,"abstract":"","PeriodicalId":49703,"journal":{"name":"Petrophysics","volume":"59 1","pages":"54-61"},"PeriodicalIF":0.9,"publicationDate":"2018-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"43413993","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
M. Rydzy, B. Anger, Stefan A. Hertel, J. Dietderich, Jorge Patino, M. Appel
{"title":"Investigation of Salt-Bearing Sediments Through Digital Rock Technology Together With Experimental Core Analysis","authors":"M. Rydzy, B. Anger, Stefan A. Hertel, J. Dietderich, Jorge Patino, M. Appel","doi":"10.30632/PETRO_059_1_A6","DOIUrl":"https://doi.org/10.30632/PETRO_059_1_A6","url":null,"abstract":"","PeriodicalId":49703,"journal":{"name":"Petrophysics","volume":"59 1","pages":"62-66"},"PeriodicalIF":0.9,"publicationDate":"2018-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"43511073","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
P. Guise, C. Grattoni, S. Allshorn, Q. Fisher, A. Schiffer
Many petrophysical properties (e.g. permeability, electrical resistivity etc.) of tight rocks are very stress sensitive. However, most mercury injection measurements are made using an instrument that does not apply a confining pressure to the samples. Here we further explore the implications of the use and analysis of data from mercury injection porosimetry or mercury capillary pressure measurements (MICP). Two particular aspects will be discussed. First, the effective stress acting on samples analysed using standard MICP instruments (i.e. Micromeritics Autopore system) is described. Second, results are presented from a new mercury injection porosimeter that is capable of injecting mercury at up to 60,000 psi into 1.5 or 1 in core plugs while keeping a constant net stress up to 15,000 psi. This new instrument allows monitoring of the electrical conductivity across the core during the test so that an accurate threshold pressure can be determined. Although no external confining pressure is applied (unconfined) when using the standard MICP instrument, this doesn’t mean that the measurements can be considered as unstressed. Instead, the sample is under isostatic compression by the mercury until it enters the pore space of the sample. As an approximation, the stress that the mercury places on the sample is equal to its threshold pressure. Thus, the permeability calculated from standard MICP data is equivalent to that measured at its threshold pressure. Not all the samples have the same stress dependency thus comparing measured permeabilities at a single stress with values calculated from standard MICP data, corresponding at different threshold pressures, can lead to erroneous correlations. Therefore, the estimation of permeabilities from standard MICP data can be flawed and uncertain unless the stress effect is included. Results obtained from the new mercury injection system, porosimeter under net stress, are radically different from those obtained from standard MICP instruments such as the Autopore IV. In particular, the measurements at reservoir conditions produce threshold pressures that are three times higher and pore throat sizes that are 1/3rd of those measured by the standard MICP instrument. The results clearly indicate that calculating capillary height functions, sealing capacity, etc. from the standard instrument can lead to large errors that can have significant impact on subsurface characterization.
{"title":"Stress Sensitivity of Mercury-Injection Measurements","authors":"P. Guise, C. Grattoni, S. Allshorn, Q. Fisher, A. Schiffer","doi":"10.30632/PETRO_059_1_A2","DOIUrl":"https://doi.org/10.30632/PETRO_059_1_A2","url":null,"abstract":"Many petrophysical properties (e.g. permeability, electrical resistivity etc.) of tight rocks are very stress sensitive. However, most mercury injection measurements are made using an instrument that does not apply a confining pressure to the samples. Here we further explore the implications of the use and analysis of data from mercury injection porosimetry or mercury capillary pressure measurements (MICP). Two particular aspects will be discussed. First, the effective stress acting on samples analysed using standard MICP instruments (i.e. Micromeritics Autopore system) is described. Second, results are presented from a new mercury injection porosimeter that is capable of injecting mercury at up to 60,000 psi into 1.5 or 1 in core plugs while keeping a constant net stress up to 15,000 psi. This new instrument allows monitoring of the electrical conductivity across the core during the test so that an accurate threshold pressure can be determined. Although no external confining pressure is applied (unconfined) when using the standard MICP instrument, this doesn’t mean that the measurements can be considered as unstressed. Instead, the sample is under isostatic compression by the mercury until it enters the pore space of the sample. As an approximation, the stress that the mercury places on the sample is equal to its threshold pressure. Thus, the permeability calculated from standard MICP data is equivalent to that measured at its threshold pressure. Not all the samples have the same stress dependency thus comparing measured permeabilities at a single stress with values calculated from standard MICP data, corresponding at different threshold pressures, can lead to erroneous correlations. Therefore, the estimation of permeabilities from standard MICP data can be flawed and uncertain unless the stress effect is included. Results obtained from the new mercury injection system, porosimeter under net stress, are radically different from those obtained from standard MICP instruments such as the Autopore IV. In particular, the measurements at reservoir conditions produce threshold pressures that are three times higher and pore throat sizes that are 1/3rd of those measured by the standard MICP instrument. The results clearly indicate that calculating capillary height functions, sealing capacity, etc. from the standard instrument can lead to large errors that can have significant impact on subsurface characterization.","PeriodicalId":49703,"journal":{"name":"Petrophysics","volume":"59 1","pages":"25-34"},"PeriodicalIF":0.9,"publicationDate":"2018-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"49297237","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
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